Downhole Directional Tool for High Dog Leg Severity
Find Innovative SolutionsGenerate Solutions
Solution Overview
Problem
Existing directional drilling systems face limitations in achieving high dog leg severity (DLS) due to the distance between the directional pad and the drill bit, which restricts the ability to form sharp curves in wellbores effectively.
Innovation Solution
A downhole tool design featuring a directional pad that contacts the wellbore wall with a contact length of 3 in. (7.6 cm) or less to the drill bit, along with a contact ratio greater than 3:1 and a directional pad angle of 0° to 5° relative to the longitudinal axis, allowing for closer positioning of the pad and active cutting elements, thereby increasing DLS.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Stability of the object's composition
If the directional pad is positioned farther from the drill bit, then the structural stability and ease of manufacture are improved, but the dog leg severity (DLS) capability deteriorates
Solution Approach 1:
The patent merges the directional pad and drill bit into a closely integrated assembly where the pad is positioned within 3 inches (preferably 1-2 inches) of the bit. This close proximity allows the directional pad to directly influence the bit's contact point with the wellbore wall, enabling high dog leg severity (up to 60° per 100 ft.) while maintaining structural integrity through the unified design of the directional drilling assembly.
2Force
If the contact length between directional pad and wellbore wall is increased, then the force distribution and stability are improved, but the dog leg severity (DLS) capability deteriorates
Solution Approach 1:
The patent optimizes the contact length parameter to a specific range (3 inches or less, preferably 1-2 inches) that balances force distribution with high DLS capability. By controlling the contact length within this optimized range, the directional pad generates sufficient force to create sharp curves (up to 60° per 100 ft.) while maintaining stable force distribution against the wellbore wall, resolving the contradiction between force requirements and DLS capability.
3Manufacturing precision
If the directional pad angle is increased, then the directional control capability is improved, but the contact stability and force distribution deteriorate
Solution Approach 1:
The patent optimizes the directional pad angle parameter to a specific range (0° to 5° relative to the longitudinal axis) that achieves high directional control (up to 60° per 100 ft.) while maintaining contact stability. This optimized angle range allows the pad to effectively steer the drill bit into sharp curves without compromising the stability of contact with the wellbore wall, resolving the contradiction between directional control and contact stability.
Data Source
AI summary
A downhole tool has a directional pad that contacts a wellbore wall at a pad contact location and a drill bit with at least one active cutting element that contacts the wellbore wall at a cutting element contact location. A contact distance between the pad contact location and the cutting element contact location being 3 in. (7.6 cm) or less.